CN102733779B - For monitoring and the control automatically of the operating parameter of downhole oil/water separation system - Google Patents
For monitoring and the control automatically of the operating parameter of downhole oil/water separation system Download PDFInfo
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- CN102733779B CN102733779B CN201210211292.4A CN201210211292A CN102733779B CN 102733779 B CN102733779 B CN 102733779B CN 201210211292 A CN201210211292 A CN 201210211292A CN 102733779 B CN102733779 B CN 102733779B
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 71
- 238000000926 separation method Methods 0.000 title claims abstract description 15
- 238000012544 monitoring process Methods 0.000 title description 3
- 239000012530 fluid Substances 0.000 claims abstract description 47
- 238000004891 communication Methods 0.000 claims abstract description 10
- 238000000034 method Methods 0.000 claims abstract description 7
- 239000007787 solid Substances 0.000 claims description 8
- 238000001514 detection method Methods 0.000 claims 1
- 238000005259 measurement Methods 0.000 abstract description 7
- 238000005507 spraying Methods 0.000 abstract description 6
- 238000005086 pumping Methods 0.000 abstract description 3
- 230000015572 biosynthetic process Effects 0.000 description 19
- 238000005755 formation reaction Methods 0.000 description 19
- 238000002347 injection Methods 0.000 description 13
- 239000007924 injection Substances 0.000 description 13
- 238000004519 manufacturing process Methods 0.000 description 13
- 239000007921 spray Substances 0.000 description 6
- 241000628997 Flos Species 0.000 description 4
- 230000001681 protective effect Effects 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 238000013481 data capture Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 229910000831 Steel Inorganic materials 0.000 description 1
- 230000001133 acceleration Effects 0.000 description 1
- 238000005119 centrifugation Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 230000005611 electricity Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000013307 optical fiber Substances 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 239000000523 sample Substances 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/38—Arrangements for separating materials produced by the well in the well
- E21B43/385—Arrangements for separating materials produced by the well in the well by reinjecting the separated materials into an earth formation in the same well
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/128—Adaptation of pump systems with down-hole electric drives
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/38—Arrangements for separating materials produced by the well in the well
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Structures Of Non-Positive Displacement Pumps (AREA)
- Control Of Non-Positive-Displacement Pumps (AREA)
- Physical Water Treatments (AREA)
Abstract
For operating a method for downhole separation system and electric submersible pump, comprising: the fluid pressure near at least one of measurement pump intake, separator inlet and wellbore bottom.At least one of flow velocity and pressure is measured at the water out place of eliminator.Pump and water out current limiter are controlled to keep optimum fluid pumping rate and the optimum spraying rate of the water be separated.Flow control system comprises the controlled valve be arranged in the water out of eliminator.At least one of pressure sensor and flowmeter is operationally connected to water out.Controller communicates with at least one signal of flowmeter with pressure sensor, and with valve operation communication.This controller operating valve, to keep selected pressure through water out and/or selected flow velocity.
Description
Chinese invention patent application (the applying date: on March 24th, 2008 of the application to be application number be 200810086260.X; Invention and created name: for the operating parameter of downhole oil/water separation system monitoring and automatically control) divisional application.
Technical field
The present invention relates generally to downhole oil/water separation system field.More particularly, the present invention relates to the automatic operation of downhole oil/water separation system, to keep preferred system operating parameters.
Background technology
Hydrocarbon production system known in the art comprises the combination of electric submersible pump (" ESP ") and downhole separation system (" DOWS ").In ESP/DOWS production system, ESP and DOWS is arranged on and is drilled through in the pit shaft of subsurface formations.This pit shaft typically has steel pipe or sleeve pipe wherein, extends to fluid will be extracted or spray the degree of depth of below the darkest subsurface formations certainly from the surface of the earth.
The centrifugal pump that ESP is rotated by motor typically.One or more hydraulic communication of subsurface formations (" producing formation " or " production area ") that the entrance of ESP and fluid will be extracted.The entrance hydraulic communication of ESP outlet or floss hole and DOWS.DOWS has two outlets, the isolated water of fluid for extracting from producing formation, and another is for remaining fluid after water is separated.Typically, the water out of this separation and the one or more hydraulic communication for the treatment of the subsurface formations (" injection stratum " or " inlet zone ") of isolated water.
DOWS is the eliminator of typical hydrocyclone or centrifugal type.Hydrocyclone comprises the equipment that the fluid that causes flowing moves in rotational path high speed wherein, moves to the radially portion of eliminator to cause closeer water.Mainly comprise the fluid confinements of the less density of oil, usually to move along the radial center be separated.Whizzer, can the motor identical from driving the motor of ESP or different motors typically by motor operation.Centrifugation apparatus uses the rotating energy of motor, and to cause the fluid entering centrifuge with High Rotation Speed, therefore water and oil retrain in the mode similar with hydrocyclone.
In order to obtain maximum benefit from ESP/DOWS production system, desired operation ESP, so that: the Fluid Volume moving across ESP/DOWS system equals producing formation and can produce fluid hourly velocity.The also operation of desired control DOWS, so that: spray the Fluid Volume entering injection stratum and be no more than the amount of spraying stratum and can accept, or alternatively, so that: the rate of flow of fluid through DOWS is no more than its separating power.When the latter, oil may discharge through water out, and processes in injection stratum.
The operating rate of automatic control ESP known in the art, to cause the fluid of ESP motion suitable amount.For example, see authorize the United States Patent (USP) the 5th, 996 of the people such as Shaw, system disclosed in No. 690 does not provide carries out any control to the fluid exported from DOWS, or any control separately to the fluid velocity that the water out from DOWS discharges.
Summary of the invention
One aspect of the present invention is the method for operating downhole separation system and electric submersible pump in pit shaft.Method according to this aspect of the invention, comprising: the fluid pressure near at least one of measurement pump intake and the entrance of eliminator and the bottom of pit shaft.At least one of flow velocity and pressure is measured at the water out place of eliminator.The speed of pump and the current limiter of water out are controlled to keep the fluid pumping rate of the optimum entering the water be separated spraying stratum and optimum spraying rate.
According to a further aspect in the invention, the flow control system used together with downhole separation system with the electric submersible pump arranged in the wellbore comprises the controlled valve be arranged in the water out of eliminator.At least one of pressure sensor and flowmeter is operationally connected to water out.Controller communicates with at least one signal of flowmeter with pressure sensor, and with valve operation communication.This controller is configured to operating valve, to keep at least one of selected pressure through water out and selected flow velocity (rate).
According to another aspect of the present invention, for operating the method for electric submersible pump in downhole separation system and pit shaft, comprising: the water out measured about eliminator exists oily parameter; And if the oily parameter instruction of measurement exists oil in the water be separated, reduce the discharge from the water out of eliminator to injection stratum.
By following description and claims, other aspects and advantages of the present invention will change clearly.
Accompanying drawing explanation
Fig. 1 shows schematically illustrating of a kind of example of setting pump in accordance with the present invention/separator system in the wellbore.
Fig. 2 shows the instance system of Fig. 1 in greater detail.
Fig. 3 shows the schematic diagram of an example of ground data acquisition/electric power and control unit.
Detailed description of the invention
Show schematically illustrating of a kind of examples produce system in Fig. 1, comprise the electric submersible pump (" ESP ") being connected to downhole separation system (" DOWS ").Be drilled through the pit shaft of the subsurface formations comprising oily producing formation 32 and water treatment or " injection " stratum 30, there is pipe or sleeve pipe 11, extend to the bottom of pit shaft from the well head 34 on earth's surface.This sleeve pipe 11 is typically isolated multiple subsurface formations with waterpower by cementing is in place, and provides the mechanical integrity with pit shaft.
The production system comprising ESP is positioned at sleeve pipe 11 inside at selected depth place.This ESP typically comprises the motor 10 of the such as three-phase AC motor being connected to protective device 12.Electromechanical transducer 10A can comprise the sensing element (not showing separately) of such as three axle accelerometers, the vibration that detectable motor 10 produces.The measured value of acceleration (vibration) can be sent to earth's surface to provide the information of the mode of operation about motor 10.Electromechanical transducer 10A also can comprise current measurement value sensing element (not showing separately), also can be sent to earth's surface to provide the information of the mode of operation about motor 10 from its measured value.This electromechanical transducer 10A also can comprise pressure sensor (not showing separately), to measure the fluid pressure in sleeve pipe 11.
Through protective device 12, the rotation of motor 10 exports and is coupled to centrifugal pump 14.The entrance of pump 14 and the inside hydraulic communication of sleeve pipe 11, so that: through entering the fluid of sleeve pipe 11 by suction pump intake with the perforation 32A of producing formation 32 relative positioning, and promoted to surface of stratum by pump 14.Pressure sensor 14A can be arranged near pump intake to measure fluid pressure.Use description to the object that this fluid pressure is measured below.
This pump 14 floss hole can be connected to the entrance of DOWS16.DOWS16 in this example can be centrifugal type eliminator.The rotor (not showing separately) of the inside of DOWS16 can be rotated by motor 10, to cause the fluid high-speed wherein moved by pump 14 to rotate, thus is pumping in fluid wherein from the inside of sleeve pipe 11, oil is separated with water.The eliminator of type hydrocyclonic can be used for other example, and the use of centrifugal type DOWS therefore in present example undesirably limiting the scope of the invention.DOWS16 comprises the oil export 16A being usually arranged on its radial center place.DOWS16 also comprises the water out 22 usually arranged close to the radial edges of DOWS16.
This oil export 16A is coupled to the production pipe 18 of the well head 34 extending to earth's surface place.Therefore, be moved into from oil export 16A all fluids producing pipe 18 and be transported to earth's surface.This production pipe 18, through being usually arranged on above producing formation 32 and the annular seal element sprayed below stratum 30, is called packer 26.In other object, this packer 26 is the outside of jointed pipe 18 and the inside of sleeve pipe 11 ordinatedly, producing formation 32 and injection stratum 30 waterpower to be isolated.
Those skilled in the art will be readily appreciated that: wherein spraying stratum 30 configuration shown in Fig. 1 be positioned at above producing formation 32 is not unique configuration that ESP/DOWS system may be used for.In other example, producing formation can be positioned at above jeting area.In this configuration, the position of potted component (packer) can be different, and water out can point to below, instead of as shown in Figure 1 upwards, but adopt the operating principle of the system of this configuration and identical in Fig. 1.Correspondingly, the relative depth on production and injection stratum is not the restriction to scope of the present invention.
This water out 22 can be connected to usually at flowmeter and/or the pressure sensor of the display of 20 places, can determine the fluid pressure in water out 22 and/or flow velocity (flow rate) by function.Will be further described below the object of this sensor and measured value.Control valve 24 is in the downstream from flowmeter and pressure sensor 20.This control valve 24 controllably can limit or stop the stream from water out 22.The outlet of this control valve 24 is coupled to injection line 28.This injection line 28 through the applicable sealing feeding port in packer 26, and can terminate in sleeve pipe 11 inside above packer 26.
In some instances, sensor 20 can comprise oil-in-water (" OIW ") sensing element (not showing separately).OIW sensing element can be such as photoacoustic sensors, ultrasonic particle monitor, optical fiber fluorescence probe or infrared sensor, or aforesaid combination.As will be further described below, if sensor 20 detects any amount of oil in the water just turning back to and spray stratum, control valve 24 can be closed or DOWS rotary speed can be controlled to reduce or to eliminate this oil.
In this example, this injection stratum 30 is arranged on above packer 26, and passes through the inside hydraulic communication of perforation 30A and sleeve pipe.Therefore, injection line 28 exports and sprays stratum 30 hydraulic communication, and isolates with producing formation 32 waterpower.Use hydraulic line 38, this control valve 24 can from earth's surface hydraulic starting, as further described following with reference to Fig. 3.In the art, the hydraulic starting valve for pit shaft is known.For example, see authorize the people such as McCalvin and transfer the United States Patent (USP) the 6th, 513 of assignee of the present invention, No. 594.Be appreciated that control valve 24 is not limited to hydraulic starting as shown in Figure 1.Also the present invention is can be used for as the electricity of two kinds of other unrestricted examples and pneumatic startup.When control valve 24 is closed completely, the whole output of DOWS16 is restricted, and flows through oil export 16A, through pipeline 18 upward to earth's surface.
The pressure sensor always shown at 35 places and/or flowmeter can be installed in the stream pipeline 33 on earth's surface.This stream pipeline 33 is connected to pipeline 18 by waterpower, typically over " wing " valve 33A arranged close to well head 34.This stream pipeline thus be used as from the floss hole of pit shaft or outlet.Alternatively, sensor 35 can be installed in the bottom (at oil export 16A) producing pipeline 18.In some implementations, in the water sensor of such as ultrasonic particle watch-dog, sensor 35 may comprise solid.In some instances, as by described below, the Fluid Volume put from well array can be controlled to reduce or eliminate any solid determining to exist the production fluid of the bottom entering pipeline 18.
The multiple sensors 20,14A arranged from pit shaft inside and the measured value of 10A can be communicated to data capture and telemetry transceiver 39.Signal format from multiple sensors is turned to applicable telemetry scheme by this telemetry transceiver 39, and for communication to earth's surface, typically edge is for providing electric power with the cable 37 of operating electrical machines 10.This telemetered signal is communicated to and is arranged on earth's surface and usually catches and control unit 36 close to the power/data at well head 34 place.As shown in Figure 1, the signal of other sensor at flowmeter/pressure sensor 35 in pipeline 33 or earth's surface place of flowing automatically also may communicate to control unit 36.The operation with control unit 36 is caught by further illustrating the power/data responding multiple measured value below.
Configuration shown in Fig. 1 expects to have system control function described below, is performed, particularly in control unit 36 by the particular system component being positioned at earth's surface.Significantly within the scope of the invention: the controlling functions of description can also utilize and be arranged on being applicable to and/or similar system control appliance execution (further illustrating with reference to Fig. 3) in well.Correspondingly, here to show and the position of system control equipment that describes is not restriction to scope of the present invention.
Fig. 2 shows the production system parts being typically connected to the lower end producing pipeline 18 in greater detail.The oil export 16A display of DOWS16 is connected to the lower end of pipeline 18, so that: all fluids leaving oil export 16A move upward along pipeline 18.The display of this pump 14 is connected to the entrance side of DOWS 16.Motor 10 and protective device 12 are also shown in its common respective position in system.This pressure sensor 14A shows the entrance 14B close to pump 14, to measure the fluid pressure at the entrance 14B place illustrated above.Also show flowmeter/pressure sensor 20 that function is connected to water out 22.This control valve 24 and valve actuator control the downstream that pipeline 38 display is arranged on flowmeter/pressure sensor 20.Also show the outlet 28 of control valve 24.Finally, from each sensor 10A, 14A, the signal of 20 connects display and is connected to data capture/telemetry transceiver 39.Export from the signal of transceiver 39 and be coupled to power cable 37.
Fig. 3 shows power/data and catches the schematic diagram with the system in control unit 36 example.This control unit 36 can comprise telemetry transceiver 42, and it can receive the decode the remote measurement from the telemetered signal sent along feed cable 37.The measured value representing the remote measurement of the decoding from the multiple sensors illustrated with reference to Fig. 1 and 2 may communicate to central processing unit (" CPU ") 40.CPU can be any based on microprocessor controller or programmable logic controller (PLC), such as General Electric Corp., and the one of selling under the trade mark FANUC of the trade mark of Fairfield, CT.The control of CPU40 exports the electric motor speed controller 44 that can be coupled to any type known in the art, such as AC electric motor speed controller.AC electric motor speed controller 44 can be operated to cause motor (10 in Fig. 1) by CPU40, and thus pump (14 in Fig. 1) and DOWS (16 in Fig. 1) work with selected rotary speed.Another control output of CPU 40 can be coupled to actuator and control 46.This actuator controls 46 provides hydraulic pressure with operation control valve (in Fig. 1 24).The parts that typical actuator controls can comprise hydraulic pump 52, and its entrance is coupled to the reservoir 48 of hydraulic fluid.The floss hole of pump through flap valve 54, and is discharged into the accumulator 56 being configured to keep selecting system fluid pressure.Pressure switch 50 can stop pump when arriving selecting system pressure.Hydraulic pressure optionally can be applied to hydraulic line through choke valve 58.This choke valve can be the power hydraulic pressure operating valve that the control being connected to CPU 40 exports.Therefore, CPU40 can through programming with the degree selecting motor speed and control valve (24 in Fig. 1) to open.
Describe the parts of the production system that can use according to the present invention, will now describe the pump (in Fig. 1 14) of the special operational realizing DOWS (in Fig. 1 16) and the operational instances of control valve (in Fig. 1 24).
First program of the CPU40 of entering able to programme is " startup " program.Starting refers to after the inertia of its regular period, the initial operation of motor (in Fig. 1 10), pump (in Fig. 1 14) and DOWS (in Fig. 1 16).Between this craticular stage, the fluid entering sleeve pipe (in Fig. 1 11) from producing formation (in Fig. 1 32) will trend towards raising its level, so that: its hydrostatic pressure head equals the fluid pressure in producing formation.Meanwhile, the water trended towards with fluid is separated by the oil of the fluid in sleeve pipe (in Fig. 1 11).After this separation, pump intake can fully slip in oil, instead of enters the combination of water and oil when fluid is discharged from producing formation (Fig. 1 32).So slip into, initial ensemble is made up of oil by the fluid escaping and enter DOWS (Fig. 1 16) from pump.If only oil is through DOWS, oil will discharge at water out (in Fig. 1 22) place.Therefore, at first, if system does not otherwise control, injected entering is sprayed stratum (in Fig. 1 30), until there is a large amount of water at pump intake by oil.In instant example, when CPU40 may be programmed in startup with operated throttle valve 58 to provide hydraulic pressure with closed control valve (in Fig. 1 24).Therefore, all fluids leaving DOWS16 upwards will produce along pipeline (in Fig. 1 18).CPU40 is able to programme to close with retentive control valve, until the pressure drop measured in the bottom (the sensor 10A by Fig. 1) of pump intake place (the pressure sensor 14A by Fig. 1) or motor to during predeterminated level when.In this moment, pump intake will be exposed to the applicable combination of water and oil.The water out of DOWS then will discharge roughly all water, as the purpose of design of DOWS.CPU40 then can operated throttle valve 58 to open control valve (in Fig. 1 24).Therefore, the water discharged from water out (Fig. 1 22) freely can pass through to and spray stratum (in Fig. 1 30).
During another example procedure is included in the operation of ESP and DOWS, use traffic table/pressure sensor (in Fig. 1 20) measures pressure and the flow velocity (flow rate) at water out (in Fig. 1 22) place.If during operation, the pressure material change in the flow velocity or water out of water out, then CPU40 can partly or entirely close to cause control valve by operated throttle valve 58.In another example, CPU40 can use the measured value of the flow velocity through water out (22 in Fig. 1), with operation control valve (in Fig. 1 24), so that: keep the selected water flow velocity entering stratum.In another example, CPU 40 can be programmed with operated throttle valve (and therefore control valve) so that: selected pressure remains in water out.
In another example, CPU40 can use the measured value from the flowmeter/pressure sensor in flowline (sensor 35 in Fig. 1), to control motor speed (and therefore speed got by the pump of ESP) and control valve aperture, to make the optimum operation of ESP and DOWS.Optimize the rate of flow of fluid that such as can be included in earth's surface and keep selected, and keep entering the selected water flow velocity spraying stratum (in Fig. 1 30).By optimizing the operation of ESP and DOWS, oil can be avoided to spray undesirably and enter injection stratum, ESP can by the surface operated the fluid (oil and/or profit combination) of scheduled volume to be risen to the earth simultaneously.
In another example, and as mentioned above, if oil-in-water sensor is included in water jet nozzle line, will determine in the water of injection to exist in any significant amounts oil condition, CPU can be programmed to limit or closed control valve (in Fig. 1 24).If the solid in water sensor is included in oil export (in Fig. 1 16A), when determining to there is solid in production fluid stream, CPU can through programming to reduce motor speed.Alternatively, as previously mentioned, use telemetering equipment, the signal produced by solid in oil-in-water and water sensor can be communicated to earth's surface.The amount of the oil that Systems Operator's observable is detected by each sensor and/or solid, and can manual adjustments motor speed and/or control valve position to correct any discomfort closing operation of production system.
Turn back to Fig. 2, CPU (in Fig. 3 40) can use the vibration and current measurement value such as undertaken by the sensor 10A on motor 10, to determine relevant motor 10 or pump 14 Problems existing.
Can provide according to the system of many aspects of the present invention and underground moisture is better controlled from disposal, and the operating more efficiently of ESP.
Although the present invention is described about a limited number of embodiment, those skilled in the art utilizes this open, will recognize: do not deviate from scope of invention disclosed herein, can expect other embodiment.Therefore, scope of the present invention will only be limited by appended claims.
Claims (7)
1. the flow control system used together with downhole separation system with the electric submersible pump arranged in the wellbore, comprising:
Controlled valve, is arranged in the water out of described eliminator;
At least one in pressure sensor and flowmeter, it is operationally connected to described water out; With
Controller, it communicates with at least one signal described in flowmeter with pressure sensor, and with described controlled valve operation communication, described controller is configured to operate described controlled valve, to keep at least one in the selected pressure and selected flow velocity of described water out.
2. system according to claim 1, wherein: described controller is arranged on earth's surface place.
3. system according to claim 1 and 2, comprise further: another flowmeter, it is operationally connected to the fluid outlet of described pit shaft, and communicate with described controller signals, described controller is configured to operate described electric submersible pump and described controlled valve, to keep the selected rate of flow of fluid through ground described fluid outlet.
4. system according to claim 1 and 2, comprise further: another pressure sensor, it is operationally connected to the ground fluid outlet of pit shaft, and communicate with described controller signals, described controller is configured to operate described electric submersible pump and described controlled valve, to keep the selected pressure in fluid outlet.
5. system according to claim 1 and 2, comprise further: oil-in-water sensor, its function is connected to described water out, and communicates with described controller signals, wherein: the hydrospace detection that described controller is configured to moving across described water out operates described controlled valve to during oil.
6. system according to claim 1, comprise further: solid state sensor in water, its function is connected to the oil export of described eliminator, and communicate with described controller signals, wherein: when described controller is configured to detect solid in the oil export of described eliminator, change the operation ratio being connected to the electric submersible pump of the entrance of described eliminator.
7., for operating a method for downhole separation system in pit shaft and electric submersible pump, comprise step:
There is provided controlled valve, described controlled valve is arranged in the water out of described eliminator;
At least one in pressure sensor and flowmeter is provided, in described pressure sensor and flowmeter described at least one be operationally connected to described water out; With
In response to signal that at least one produces described in described pressure sensor and flowmeter, control the operation of described controlled valve, to keep at least one in the selected pressure and selected flow velocity of described water out.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US11/691,877 US7828058B2 (en) | 2007-03-27 | 2007-03-27 | Monitoring and automatic control of operating parameters for a downhole oil/water separation system |
| US11/691,877 | 2007-03-27 | ||
| CN200810086260XA CN101275465B (en) | 2007-03-27 | 2008-03-24 | Monitoring and automatic control of operating parameters for a downhole oil/water separation system |
Related Parent Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN200810086260XA Division CN101275465B (en) | 2007-03-27 | 2008-03-24 | Monitoring and automatic control of operating parameters for a downhole oil/water separation system |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN102733779A CN102733779A (en) | 2012-10-17 |
| CN102733779B true CN102733779B (en) | 2015-10-14 |
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Family Applications (3)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201210212506.XA Expired - Fee Related CN102748003B (en) | 2007-03-27 | 2008-03-24 | For operating the method for downhole separation system in pit shaft and electric submersible pump |
| CN200810086260XA Expired - Fee Related CN101275465B (en) | 2007-03-27 | 2008-03-24 | Monitoring and automatic control of operating parameters for a downhole oil/water separation system |
| CN201210211292.4A Expired - Fee Related CN102733779B (en) | 2007-03-27 | 2008-03-24 | For monitoring and the control automatically of the operating parameter of downhole oil/water separation system |
Family Applications Before (2)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201210212506.XA Expired - Fee Related CN102748003B (en) | 2007-03-27 | 2008-03-24 | For operating the method for downhole separation system in pit shaft and electric submersible pump |
| CN200810086260XA Expired - Fee Related CN101275465B (en) | 2007-03-27 | 2008-03-24 | Monitoring and automatic control of operating parameters for a downhole oil/water separation system |
Country Status (5)
| Country | Link |
|---|---|
| US (1) | US7828058B2 (en) |
| CN (3) | CN102748003B (en) |
| GB (3) | GB2459993B (en) |
| NO (1) | NO20081449L (en) |
| RU (1) | RU2465451C2 (en) |
Families Citing this family (45)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US8291979B2 (en) | 2007-03-27 | 2012-10-23 | Schlumberger Technology Corporation | Controlling flows in a well |
| US7828059B2 (en) * | 2007-08-14 | 2010-11-09 | Baker Hughes Incorporated | Dual zone flow choke for downhole motors |
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Also Published As
| Publication number | Publication date |
|---|---|
| CN101275465B (en) | 2013-04-24 |
| RU2465451C2 (en) | 2012-10-27 |
| GB2448017B (en) | 2010-01-06 |
| GB0914527D0 (en) | 2009-09-30 |
| GB2463140A (en) | 2010-03-10 |
| CN102748003A (en) | 2012-10-24 |
| GB0801717D0 (en) | 2008-03-05 |
| GB2459993A (en) | 2009-11-18 |
| GB2459993B (en) | 2010-11-17 |
| NO20081449L (en) | 2008-09-29 |
| RU2008111643A (en) | 2009-10-10 |
| US7828058B2 (en) | 2010-11-09 |
| CN102733779A (en) | 2012-10-17 |
| GB2448017A (en) | 2008-10-01 |
| GB2463140B (en) | 2010-12-08 |
| CN102748003B (en) | 2016-04-27 |
| US20080236821A1 (en) | 2008-10-02 |
| GB0914526D0 (en) | 2009-09-30 |
| CN101275465A (en) | 2008-10-01 |
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